Wind developers across South-East Europe are moving into a markedly different operating environment in 2026. The first decade of growth was defined by build-out—securing sites, navigating permitting, and locking in feed-in tariffs that turned wind farms into predictable infrastructure assets. That phase is ending. What is replacing it is a market where price volatility, system constraints and flexibility determine value as much as installed capacity.
The region now hosts a diverse group of operators, ranging from early entrants such as Akuo Energy in Montenegro and Masdar-backed platforms in the Western Balkans, to large utilities and developers including PPC Group, Enel Green Power, EDP Renewables, Nala Renewables, and a growing layer of regional sponsors. Collectively, they control a portfolio that is approaching several gigawatts across Serbia, Romania, Bulgaria, Greece and Croatia, with pipelines that extend well beyond 10 GW when including projects under development.
In the past, these companies competed primarily on access to wind resource and regulatory frameworks. In Q1 2026, competition is increasingly about portfolio strategy—how assets are structured, how output is monetised, and how risk is managed in a system where renewable generation is no longer marginal.
From development success to market exposure
The early generation of wind projects in SEE was built under feed-in tariff regimes or CfD-style frameworks, ensuring stable revenue and relatively straightforward financing. This created a class of assets that behaved more like regulated utilities than merchant generators.
That model is now being replaced. As markets integrate and subsidy frameworks evolve, wind companies are being exposed—partially or fully—to wholesale price dynamics. This shift is visible across the region:
- In Romania, developers are increasingly structuring projects around CfDs combined with merchant exposure, reflecting a hybrid revenue approach.
- In Greece, auction-based systems and maturing balancing markets are pushing operators toward more active participation in power trading.
- In Serbia and the Western Balkans, new projects are being designed with corporate PPAs and market-linked components, even where legacy support mechanisms remain.
The implication is straightforward: revenue is no longer defined by contracted tariffs alone. It is shaped by capture prices, which depend on when wind is produced relative to market demand and competing renewable output.
Portfolio divergence: Scale vs quality
A clear divergence is emerging between companies that built early, high-quality assets and those entering the market at scale.
Operators such as Akuo Energy (Krnovo) and established European utilities with strong site selection have portfolios characterised by:
- higher capacity factors
- stable output profiles
- stronger debt metrics
These assets remain attractive to institutional investors and lenders, particularly as refinancing cycles begin.
By contrast, newer portfolios—particularly those built rapidly or through opportunistic site aggregation—face more complex economics. Lower wind resource quality, combined with higher competition for grid access, can lead to:
- reduced load factors
- tighter margins
- greater exposure to curtailment and balancing costs
This divergence is becoming more pronounced as markets move toward merchant exposure. High-quality assets maintain value; marginal projects face compression.
Romania and Greece: The regional centres of gravity
Two markets stand out in Q1 2026 as defining the direction of wind development in SEE: Romania and Greece.
Romania combines strong wind resource, large system size, and growing flexibility needs. It is attracting significant capital not only for wind generation but also for co-located storage and hybrid projects, positioning itself as a leading hub for integrated renewable portfolios.
Greece, meanwhile, has reached a level of renewable penetration where system effects are already visible. Wind and solar output are now large enough to influence price formation directly, creating both opportunity and risk for operators. Companies active in Greece are increasingly investing in:
- storage
- advanced forecasting
- trading capabilities
to manage volatility and optimise returns.
These two markets are effectively setting the template for the rest of SEE.
The next layer: Hybridisation as standard strategy
Across the region, wind companies are converging on a common conclusion: standalone wind assets are no longer sufficient.
Hybridisation—combining wind with solar and battery storage—is becoming central to portfolio strategy. The logic is both operational and financial:
- Solar complements wind generation profiles
- Batteries enable time-shifting and balancing
- Combined assets improve capture prices and reduce volatility
For developers, the economics are increasingly compelling. Hybrid projects can:
- increase revenue stability
- reduce imbalance costs
- unlock additional revenue streams from ancillary services
In markets where price spreads between low and high demand periods are widening, these benefits translate directly into higher returns.
Balancing costs and curtailment: The hidden margin erosion
As renewable penetration increases, wind companies are facing costs that were negligible in the early development phase.
Balancing costs are rising as system operators manage greater variability. Wind producers must invest in better forecasting and operational control to minimise penalties.
Curtailment risk is also emerging, particularly in markets where grid infrastructure has not kept pace with capacity additions. During periods of high wind output, generation may exceed both domestic demand and export capacity, forcing operators to reduce output.
These factors erode margins and introduce new layers of uncertainty. For companies with large portfolios, they also create a need for centralised trading and optimisation functions, moving beyond the passive operation model that characterised earlier projects.
Institutional capital and the evolution of ownership structures
The capital structure of wind companies in SEE is also evolving. Early projects were typically financed by a combination of:
- international banks
- development finance institutions
- strategic investors
This ensured disciplined project selection and relatively transparent ownership.
The current expansion phase is attracting a broader mix of capital, including:
- infrastructure funds seeking yield
- private equity targeting growth
- regional investors entering the renewable space
This diversification increases liquidity but also introduces variability in governance and investment horizon. Some investors prioritise long-term stable returns; others are focused on shorter-term value creation and exit strategies.
As the market matures, the ability to align capital structure with asset strategy will become increasingly important.
Cross-border integration: From national assets to regional platforms
One of the defining features of Q1 2026 is the growing importance of cross-border electricity flows. SEE markets are no longer isolated; they are part of an interconnected system where power moves toward higher-priced zones.
For wind companies, this creates new opportunities:
- exporting excess generation
- accessing higher-value markets
- diversifying revenue streams
But it also introduces new risks:
- exposure to external price shocks
- dependency on interconnection capacity
- increased competition from neighbouring producers
Companies with access to multiple markets and strong trading capabilities are better positioned to capture value in this environment.
Outlook: 2026–2030 — From capacity expansion to system integration
The trajectory for wind companies in South-East Europe is clear. Installed capacity will continue to grow rapidly, but the determinants of value will shift.
In a base case, capacity expands steadily, supported by hybridisation and gradual improvements in grid infrastructure. Companies adapt to market exposure, and returns remain stable, albeit more variable.
In an upside scenario, successful integration of storage and stronger interconnection transform SEE into a regional export hub, allowing wind companies to capture higher-value markets and improve returns.
In a downside scenario, insufficient grid capacity and flexibility lead to rising curtailment and declining capture prices, compressing margins and increasing operational risk.
A market defined by strategy, not just scale
The defining characteristic of the SEE wind sector in 2026 is that scale alone is no longer sufficient. The next phase will be shaped by:
- asset quality
- portfolio design
- flexibility integration
- market participation capability
Wind companies are no longer simply developers or operators. They are becoming energy platform managers, responsible for optimising generation, managing risk, and navigating increasingly complex market dynamics.
The transition is still underway, but the direction is clear. South-East Europe’s wind sector is moving from a build-out story to a system integration story, where value is determined not just by how much energy is produced, but by how effectively it is delivered, stored and traded.
